9 7/B'' X Production Casing Design · PDF file9 7/B'' X 7'' Production Casing Design Report For ... Centralizer Parameters ... Macoodo Prospect MC 252 #I -9.875 X 7 prod Casing BP

BP AMERICA PRODUCTION COMPANY POBox22024 Tulsa, OK 74121-2024

Macondo #1

9 7/B'' X 7'' Production Casing Design Report

For: Brian Morel Date: April 18, 2010

Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user' s own risk.

HALLIBURTON

WIT: ____ _

HALLIBURTON BP AMERICA PRODUCTION COMPANY Macondo #1

Macoodo Prospect MC 252 #I - 9.875 X 7 prod Casing

Table of Contents

1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 1.10 1.11 1.12 1.13

2.0 2.1 2.2

3.0 3.1 3.2 3.3 3.4

4.0 4.1 4.2 4.3 4.4

5.0 5.1 5.2 5.3 5.4 5.5 5.6 5.7 5.8

6.0 6.1 6.2 6.3 6.4 6.5

Design ................................................................................................... ..... ................................. .................... 3 Customer Information ................................................................................................................................. 3 Parameters ..................... ............................................... ......................................................................... ... .. 3 Well bore Orientation .................................................................................................................................. 4 Surface Lines .............................................................................................................................................. 6 Wellbore Geometry .................................................................................................................................... 7 Pumping Schedule ......... ...... .. ................................................................................................................... .. 8 Fluid Rheology - Generalized Herschel Bulkley ... .. ................................................................................... 9 Fluid Rheology- Bingham Plastic ............................................................................................................ l O Temperature Input ......................................... ........................................................................................... ! 0 Temperature Profile, Temperature Profile ! ............................................................................................. ! 0 Fracture Gradient/Pore Pressure Profile .................................. ................................................................. 11 Critical Velocity- Fracture Zone .............................................................................................................. l1 Critical Velocity - Reservoir Zone .................................................................... .................................. ..... 11

Tuned Spacer ........................................................................................ ......................................................... 12 Tuned Spacer Parameters, 3. Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS III, Bingham Plastic ..... 12 Tuned Spacer Parameters, 6. Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS III, Bingham Plastic ..... 13

Foam ......................................................................................................................................... ..................... 14 Foam Design Parameters .......................................................................................................................... l4 Foam Pumping Schedule for Liquids ....................................................................................................... 14 Foam Pumping Schedule for Gas ............................................................................................................. 15 Foam Slurry Data ................................................................... ... ........ ... .................................................... 15

Centralizers ............................ ......................... ....... .......... ............................................................................. 16 Centralizer Parameters .................................................................. ....................... ........... ....... ................... 16 Centralizer Specifications ......................................................................................................................... 16 Constant Spacing/Standoff Centralizer Intervals ...................................................................................... l6 Centralizer Placement ............................................................... ............................... .. ............................... l6

Simulation .............. ..... ........ ................ .. ........................................................................................................ 17 Volume and Pressure Results ... ........ ..... ................................................. ................. ................................. 17 Volume and Rate Calculations ............................................................... ............... ................................... 17 Horsepower, Pressure, Freefa11 ................................................................................................................. 18 Gas Flow Potential .............. ................................................................................................. .................... 18 Pressure to Break Circulation - Hydrostatic Pressures ............................................................................. 18 Pressure to Break Circulation ........................................................... .. ........................... ............ .. ........ ..... 18 Final Position of Stages .... ............. ..... ...................................................................................................... 19 Final Annular Fluid Density ..................................................................................................................... 20

Attachments ................................................................................................................................................... 23 Fluid Positions (graph) ..................................................................................................... ................ ........ 23 Circ Pressure & Density - Frac Zone (graph) .. ... .. ... .......... ... ........................................... ....... ....... ........... 24 Circ Pressure & Density - Res Zone (graph) ...... .. ......................................................................... ........... 25 Downhole Pressure Profiles (graph) ......... ................................................................................................ 26 MC252#l_BP01_Svy_Rec_NO_ 4_10_10.txt (text) ................................................................................ 27

2 Created: April 18, 20 l 0 at 11:25 AM

OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

1.0 DESIGN

1.1 Customer Information

Customer Sales Order Job Configuration Well Name Well Number Start Time County State UWI/API Country H2S Present C02 Present Customer Representative Service Representative Design Name

Comment Injection Path

1.2 Parameters

Fracture Zone Measured Depth Fracture Zone Gradient Fracture Zone Density Fracture Zone Pressure Reservoir Measured Depth Reservoir Pore Pressure Reservoir Zone Gradient Reservoir Zone Density Back Pressure Height - Mud Line to Mean Sea Level

BP AMERICA PRODUCTION COMPANY Macondo #1

Macoodo Prospect MC 252 #I - 9.875 X 7 prod Casing

BP AMERICA PRODUCTION COMPANY

N2 Foamed Cement Macon do #1 Thursday, April15, 2010

Louisiana

United States of America Unknown Unknown Brian Morel Jesse Gaqliano Macondo Prospect MC 252 #1 - 9.875 X 7 - with 7 bbls Base Oil

Casing

18305.0 ft 0.779 psi/ft 15.00 lb/qal 14255 psi

18200.0 ft 13197 osi 0.726 psi/ft 13.97 lb/qal

0 psi 4992.0 ft

Height - Mean Sea Level to Rotarv Kellv Bushinq 75.0 ft Sea Water Density Returns To Surface Simulator Volume Increment Surface Iron Displacement Shoe Track Length Additional Pressure to Seat Plug Eccentricity Enhanced Calculations Erodibility Enhanced Calculations Mud Erodibility Measured Depth Mud Erodibility Number Mud Required Shear Stress Use Coupling Information

3

8.54

5.00 0.41

189.0 500 No

Yes 17168.0

20.69 29.00

No

lb/qal

bbl bbl ft psi

ft

lbf/( 1 OO*ft2 )

Created: April l8, 2010 at 11:25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

1.3 Wellbore Orientation

Measured Depth True Vertical Depth

ft ft 0.0 0.0

5067.0 5067.0 5526.0 5525.9 5621.0 5620.9 5719.0 5718.8 5815.0 5814.8 5908.0 5907.8 6004.0 6003.8 6099.0 6098.8 6195.0 6194.8 6304.0 6303.8 6401.0 6400.8 6495.0 6494.8 6590.0 6589.8 6685.0 6684.8 6780.0 6779.8 6873.0 6872.8 6971 .0 6970.8 7057.0 7056.8 7159.0 7158.8 7254.0 7253.8 7350.0 7349.8 7443.0 7442.8 7538.0 7537.8 7633.0 7632.8 7727.0 7726.8 7821.0 7820.8 7921 .0 7920.8 8000.0 7999.8 8096.0 8095.7 8192.0 8191.7 8289.0 8288.7 8382.0 8381 .7 8477.0 8476.7 8573.0 8572.7 8667.0 8666.7 8762.0 8761.7 8854.0 8853.7 8917.0 8916.7 9187.0 9186.6 9327.0 9326.6 9463.0 9462.6 9603.0 9602.6 9736.0 9735.6 9874.0 9873.6

10004.0 10003.6 10150.0 10149.6 10285.0 10284.6

BP AMERICA PRODUCTION COMPANY Macondo#l

Macondo Prospect MC 252 #1 - 9.875 X 7 prod Casing

Deviation Build Angle Azimuth

0

0.0 0.0 2 .0 1.6 1.3 1.1 0.9 0 .9 0.7 0.6 0.5 0.1 0.0 0 .0 0.0 0 .1 0.1 0 .1 0.0 0.0 0.0 0.0 0 .1 0.1 0 .0 0 .0 0.0 0.1 1.1 0 .9 0.0 0.2 0.1 0.1 0 .1 0 .1 0.1 0 .1 0.1 2.5 0.4 0.4 0 .5 0.4 0.4 0 .3 0.4 0.4

4

0 /(1 OO*ft) 0

0 .0 0.00 0 .0 0.43 101.4

-0 .33 97.2 -0.32 96.8 -0.22 91.4 -0.20 93.4 -0.08 92.6 -0.15 89.3 -0.11 86.6 -0.11 83.3 -0.41 82.2 -0.06 119.7 0 .00 211.6 0.00 318.1 0.06 42.6 0.01 268.0 0.02 300.4

-0.10 100.6 0.01 240.7

-0.01 220.7 0.01 273.7 0.02 135.0 0.00 171 .6

-0.02 333.4 -0.04 359.8 0.03 335.2 0.09 181 .0 1.19 20.0

-0.13 17.0 -0.95 16.1 0 .21 225.8

-0.18 34.1 0.00 324.5 0.03 9.4 0.00 46.6

-0.03 86.7 0 .03 9.4

-0.05 46.6 0 .89 106.3

-1.45 96.0 -0.04 90.8 0 .05 125.7

-0.05 154.0 0 .01 141.0

-0.11 157.9 0.08 162.3 0.06 184.5

Created: April18, 2010 at 11:25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON


ft ft 10424.0 10423.6 10563.0 10562.6 10701.0 10700.6 10839.0 10838.6 10977.0 10976.6 11114.0 11113.5 11252.0 11251 .5 11390.0 11389.5 11528.0 11527.5 11665.0 11664.5 11796.0 11795.5 11934.0 11933.0 12070.0 12067.9 12209.0 12205.0 12347.0 12341.0 12484.0 12476.4 12622.0 12613.1 12760.0 12750.1 12896.0 12885.6 13034.0 13023.4 13112.0 13101.4 13172.0 13161.4 13310.0 13299.4 13448.0 13437.4 13585.0 13574.4 13721.0 13710.3 13859.0 13848.3 13998.0 13987.3 14133.0 14122.3 14273.0 14262.3 14549.0 14538.3 14684.0 14673.3 14816.0 14805.3 14950.0 14939.3 15081.0 15070.3 15264.0 15253.3 15406.0 15395.2 15540.0 15529.2 15673.0 15662.2 15805.0 15794.2 15939.0 15928.2 16072.0 16061.2 16204.0 16193.2 16333.0 16322.2 16470.0 16459.2 16604.0 16593.1 16729.0 16718.1 16870.0 16859.1 17004.0 16993.1



Deviation Build Angle Azimuth

0

0.5 0.5 0.5 0.5 0.6 0.7 0.6 0.5 0.5 0.4 3.1 5.6 9.1 9.9 9.2 8.6 7.3 6.0 4.3 1.3 0.7 0.6 0.9 0.6 0.6 0.7 0.7 0.8 0.6 0.8 0.5 0.3 0.7 0.7 0.6 0.7 0.7 0.7 0.6 0.6 0.8 0.9 0.7 0.7 0.8 0.9 0.8 0.8 0.7

5

0 /(100*ft) 0

0.02 182.7 0.00 210.6 0.00 205.5 0.00 208.5 0.07 204.1 0.08 205.5

-0.04 216.2 -0.08 220.5 -0.04 191.9 -0.05 185.2 2.11 267.9 1.79 264.1 2.58 264.3 0.58 262.3

-0.52 262.5 -0.44 263.4 -0.99 261.1 -0.91 261.6 -1 .22 262.0 -2.20 264.7 -0.79 257.8 -0.08 261.4 0.20 272.4

-0.18 276.6 -0.01 274.8 0.04 267.5 0.01 273.8 0.08 265.3

-0.18 274.2 0.17 262.4

-0.12 291.1 -0.1 2 268.7 0.27 235.4 0.03 230.4

-0.05 241.4 0.02 214.5 0.05 228.4

-0.04 223.8 -0.09 242.8 0.02 234.9 0.1 2 246.9 0.09 240.6

-0.13 235.1 -0.02 229.1 0.07 235.1 0.07 222.2

-0.07 224.2 0.02 233.9

-0.10 206.2

Created: April 18, 20 1 0 at 11 :25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON


ft ft 17136.0 17125.1 17318.0 17307.1 17455.0 17444.1 17592.0 17581.1 17728.0 17717.1 17867.0 17856.1 18003.0 17992.1 18138.0 18127.1 18305.0 18294.0

1.4 Surface Lines

Equipment Length

ft 2" 15,000 psi Discharge Iron 120.0



Deviation

0

0.9 0.6 0.4 0.3 0.4 0.4 0.6 0.7 0.4

Elev. OD Change

ft in 45.0 2.620

6

Build Angle Azimuth

0 /(1 OO*ft) 0

0.19 219.9 -0.15 175.5 -0.20 187.9 -0.04 157.7 0.05 70.5 0.00 32.2 0.18 19.3 0.09 35.9

-0.22 38.2

ID Friction Numln Factor Parallel

in 1.870 1.00 1

Created: April 18, 2010 at 11:25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

1.5 Wellbore Geometry

MD Hole Ex. Hole Dia.

ft % in 5067.0 0.00 19.500 5069.0 0.00 14.920

11185.0 0.00 14.920 12485.0 0.00 12.375 12800.0 0.00 12.375 14803.0 0.00 10.711 17168.0 0.00 8.625 17284.5 0.00 9.700 17352.0 0.00 10.139 17579.5 0.00 10.176 17619.5 0.00 10.555 17639.0 0.00 10.660 17680.5 0.00 10.901 17686.0 0.00 11.578 17719.5 0.00 10.601 17774.0 0.00 10.417 17787.0 0.00 11.140 17803.5 0.00 11.180 17810.5 0.00 10.167 17829.5 0.00 11.469 17848.5 0.00 11.474 17864.0 0.00 10.642 17890.5 0.00 10.740 17910.5 0.00 10.601 17935.0 0.00 10.688 18061.0 0.00 10.550 18105.0 0.00 9.502 18107.5 0.00 11.215 18191 .5 0.00 8.755 18305.0 0.00 8.998

7



Casing OD

in 6.625

14.300 9.875 9.875 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000 7.000

Casing ID Casing Weight

in lb/ft 5.291 40.000 8.625 62.800 8.598 62.800 8.598 62.800 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000 6.143 32.000

Created: April 18, 20 I 0 at 11 :25 AM OptiCem v6.4.8 (OC v6.4 .8)

HALLIBURTON

1.6 Pumping Schedule

No. Description



Density Rate Volume Duration lb/gal bpm bbl min

1 Macondo 9 7 /8" X 7" Prod CasinQ - 14.17 QP9 14.17 1.00 0.00 0.00 2 6.7 ppg Base Oil Macondo 6.50 3 Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg 14.30

TS Il l 4 Macondo Foamed Slurry- 16.74 PDQ 16.74

5-1 Macondo Foamed Slurry- 16.74ppg 16.74 5-2 Macondo Foamed Slurry- 16.74 PDQ 16.74 5-3 Macon do Foamed Slurry - 16.7 4 ppg 16.74 5-4 Macondo Foamed Slurry - 16.7 4 ppg 16.74

Top Plug 6 Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg 14.30

TS III 7 Macon do 9 7 /8" X 7" Prod CasinQ - 14.17 ppg 14.17

Total

8

4.00 7.00 1.75 4.00 72.00 18.00

2.00 5.26 2.63 2.00 15.48 7.74 2.00 23.50 11 .75 2.00 0.29 0.14 2.00 6.93 3.46

4.00 20.00 5.00

4.00 856.93 214.23 1007.39 264.71

Created: April 18, 20 l 0 at ll :25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON BP AMERICA PRODUCTION COMPANY Macoodo#l

Macoodo Prospect MC 252 #1 - 9.875 X 7 prod Casing

1.7 Fluid Rheology- Generalized Herschel Bulkley

Fluid Temp. Foam m n Dens it

y OF lb/gal

Macondo 9 7/8" X 7" 40 1.00 0.87 Prod Casing - 14.17 ppg

100 0.57 0.57

150 1.00 0.89

6. 7 ppg Base Oil 75 1.00 1.00 Macondo

120 1.00 1.00

150 1.00 1.00

Macondo Foamed 80 1.00 1.00 Slurry - 16.7 4 ppg (Class H)

9

Tauo Mulnf Speed Dial

I bfl( 1 OO*ft2) CD rom 7.38 99.14 600 187.00

300 106.00 200 76.00 100 45.00

6 10.00 3 9.00

5.25 33.85 600 97.00 300 57.00 200 41.00 100 27.00

6 8.00 3 7.00

7.22 25.87 600 62.00 300 37.00 200 27.00 100 18.00

6 8.00 3 7.00

1.56 3.02 600 8.00

300 4.00 200 3.00 100 2.00

6 2.00 3 2.00

0.66 2.30 600 5.00 300 3.00 200 2.00 100 1.00

6 1.00 3 1.00

0.66 2.30 600 4.00 300 2.00 200 2.00 100 1.00

6 2.00 3 2.00

0.56 87.92 600 180.00

300 84.00 200 56.00 100 28.00

Created: April 18, 20 I 0 at ll :25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

Fluid Temp. Foam m Dens it

y OF lb/gal

135 1.00

80 14.50 1.00

BP AMERICA PRODUCTION COMPANY Macoodo #1


n TauO Mulnf Speed Dial

lbf/(100*ft2) cp rpm 60 26.00 30 8.00 20 6.00 10 4.00 6 2.00 3 2.00

1.00 0.85 62.11 600 130.00 300 56.00 200 40.00 100 20.00 60 12.00 30 8.00 20 6.00 10 4.00 6 4.00 3 4.00

1.00 1.30 77.18 600 14.00 300 7.00 200 5.00 100 3.00

60 1.00 30 1.00 6 1.00 3 1.00

1.8 Fluid Rheology- Bingham Plastic

Fluid Temp. PV OF cp

Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg 80 51 .98 TS Ill

1.9 Temperature Input

Entered BHCT Method Surface Outlet BHCT BHST

80 Of 120 °f 135 Of

Of

1.10 Temperature Profile, Temperature Profile 1

Measured Depth Casing Circulating Temperature

ft OF

0.0 18305.0

10

yp Speed Dial lbf/(1 OO*ft2) rpm

30.00

80 135

Annulus Circulating Temperature

OF 120 135

Created: Aprill8, 2010 at 11 :25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON BP AMERICA PRODUCTION COMPANY Macondo#l


1.11 Fracture Gradient/Pore Pressure Profile

Measured True Pore Reservoir Reservoir Depth Vertical Pressure Gradient Density

Depth ft ft psi psi/ft lb/gal

17163.0 17152.1 12304 0.717 13.81 17700.0 17689.1 12873 0.728 14.01 18200.0 18189.1 18305.0 18294.0 13265 0.725 13.96

1.12 Critical Velocity - Fracture Zone

Stage Description Critical Rate

bpm Macondo 9 7/8" X 7" Prod Casing -14.17 9.89 ppg 6.7 ppg Base Oil Macondo 3.01 Macondo 9 7/8" X 7" Prod Casing- 14.3 18.70 ppg TS Ill Macondo Foamed Slurry- 16.74 ppg 11 .55 Macondo Foamed Slurry- 16.74 ppg 11 .55 Macondo 9 7/8" X 7" Prod Casing- 14.3 18.70 PDQ TS Ill Macondo 9 7/8" X 7" Prod Casing- 14.17 9.89 ppg

Based on annular segment at fracture zone MD of 18305.0 ft.

1.13 Critical Velocity - Reservoir Zone

Stage Description Critical Rate

bpm Macon do 9 7 /8" X 7" Prod Casing - 14.17 9.89 ppg 6. 7 ppg Base Oil Macon do 3.01 Macondo 9 7/8" X 7" Prod Casing- 14.3 18.70 PDQ TS Ill Macondo Foamed Slurry- 16.74 ppg 11.56 Macondo Foamed Slurry- 16.74 ppg 11.56 Macondo 9 7/8" X 7" Prod Casing- 14.3 18.70 PPQ TS Ill Macon do 9 7 /8" X 7" Prod Casing - 14.17 9.89 ppg

Based on annular segment at reservoir zone MD of 18200.0 ft.

11

Fracture Fracture Fracture Gradient Density Pressure

psi/ft lb/gal psi 0.754 14.51 12928

0.754 14.51 13709 0.779 15.00 14255

Critical Velocity GHB Effective Reynold's Number

ft/s 5.31 3561.21

1.62 3852.90 10.04 3563.65

6.20 3046.64 6.20 3046.64

10.04 3563.65

5.31 3561 .21

Critical Velocity GHB Effective Reynold's Number

ft/s 5.31 3561.00

1.62 3852.89 10.04 3563.65

6.20 3046.36 6.20 3046.36

10.04 3563.65

5.31 3561.00

Created: April 18, 20 l 0 at 11 :25 AM OptiCem v6.4.8 (OC v6.4.8)


.Macondo Prospect MC 252 #1 - 9.875 X 7 prod Casing

2.0 TUNED SPACER

2.1 Tuned Spacer Parameters, 3. Macondo 9 7/8" X 7" Prod Casing -14.3 ppg TS Ill, Bingham Plastic

Density Calculated YP Calculated PV Temperature Use Job Design Zone of Interest Measured Depth Displacement Efficiency Hole Dia. Standoff Pipe OD Rate Mud Erodibility Number Required Shear Stress Density PV yp

Laboratory Volume This Tuned Spacer was designed to meet the above conditions. Check pipe OD, hole dia., standoff, rate, erodibility number, density, PV, and YP for any differences in the final job design and simulation. Simulated Downhole Rate Simulated Downhole MD

12

14.30 lb/gal 30.00 lbf/(1 OO*ft2

)

51.98 cp 190 OF Yes

18300.0 ft 100.00 8.998 in 80.73 % 7.000 in

4.00 bpm

20.69 29.00 lbf/(1 OO*ft2)

14.17 lb/gal 23.83 cp

6.27 lbf/(1 OO*ft2 )

600.00 cm3

3.99 bpm 18305.0 ft

Created: April 18, 2010 at 11 :25 AM OptiCem v6.4.8 (OC v6.4.8)



2.2 Tuned Spacer Parameters, 6. Macondo 9 7/8" X 7" Prod Casing - 14.3 ppg TS Ill, Bingham Plastic

Density Calculated YP Calculated PV Temperature Use Job Design Zone of Interest Measured Depth Displacement Efficiency Hole Dia. Standoff Pipe OD Rate Mud Erodibility Number Required Shear Stress Density PV yp Laboratory Volume This Tuned Spacer was designed to meet the above conditions. Check pipe OD, hole dia., standoff, rate, erodibility number, density, PV, and YP for any differences in the final job design and simu lation. Simulated Downhole Rate Simulated Downhole MD

13

14.30 lb/gal 30.00 lbf/( 1 OO*ft2

)

51.98 cp 190 OF Yes

18300.0 ft 100.00

8.998 in 80.73 % 7.000 in

4.00 bpm

20.69 29.00 lbf/(1 OO*ft2) 14.17 lb/gal 23.83 cp 6.27 lbf/( 1 OO*ft2

)

600.00 cm3

bpm 18305.0 ft




3.0 FOAM

3.1 Foam Design Parameters

Constant or Stages Gas Flow Calculation Method

Foaming Agents in Mix Water (volume based) Surfactant Stabilizer

Fracture Zone Measured Depth Fracture Pressure Fracture Gradient Fracture Density Calculated Hydrostatic Pressure Calculated Hydrostatic Pressure Gradient Calculated Hydrostatic Density

Reservoir Zone Measured Depth Pore Pressure Reservoir Gradient Reservoir Density Calculated Hydrostatic Pressure Calculated Hydrostatic Pressure Gradient Calculated Hydrostatic Density

3.2 Foam Pumping Schedule for liquids

Stg Start Pump Base Cum. Cern. Time Rate Slurry Base Mix

Vol. Slurry Water Vol. Vol.

min bpm bbl bbl bbl 1 0.00 1.00 0.00 0.00 0.00 2 0.00 4.00 7.00 7.00 0.00 3 1.75 4.00 72.00 72.00 0.00 4 19.75 2.00 5.26 5.26 2.54

5-1 22.38 2.00 15.48 15.48 7.46 5-2 30.12 2.00 23.50 38.98 11.33 5-3 41.87 2.00 0.29 39.27 0.14 5-4 42.02 2.00 6.93 46.20 3.34

6 45.48 4.00 20 .00 20.00 0.00 7 50.48 4.00 856.93 856.93 0.00

14

1.50 % 0.00 %

18305.0 ft 14255 psi 0.779 psi/ft 15.00 lb/gal

13485 psi 0.737 psi/ft 14.19 lb/gal

18200.0 ft 13197 psi 0.726 psi/ft 13.97 lb/gal

13405 psi 0.737 psi/ ft 14.19 lb/gal

Cum. Foam Foam Foaming Cern. Agents Agents Agents Mix Rate Vol. Cum.

Water Job Vol. Volume bbl gpm gal gal

0.00 0.0 0.0 0.00 0.0 0.0 0 .0 0.00 0.0 0.0 0.0 2.54 0.0 0.0 0.0 7.46 0.6 4.7 4.7

18.79 0.6 7.1 11.8 18.93 0.0 0.0 11.8 22.27 0.0 0.0 11.8

0.00 0.0 0.0 11 .8 0.00 0.0 0.0 11.8


HALLIBURTON

3.3 Foam Pumping Schedule for Gas

Stg Start Pump Starting Starting Time Rate Gas Gas

Cone. Rate min bpm scf/bbl scfm

1 0.00 1.00 0.000 0 2 0.00 4.00 0.000 0 3 1.75 4.00 0.000 0 4 19.75 2.00 0.000 0

5-1 22.38 2.00 583.381 1167 5-2 30.12 2.00 583.381 1167 5-3 41.87 2.00 0.000 0 5-4 42.02 2.00 0.000 0

6 45.48 4.00 0.000 0 7 50.48 4.00 0.000 0

3.4 Foam Slurry Data

No. Description

1 Macondo 9 7/8" X 7" Prod Casing -14.17 ppg

2 6. 7 ppg Base Oil Macondo 3 Macondo 9 7/8" X 7" Prod Casing- 14.3

ppg TS Ill 4 Macondo Foamed Slurry- 16.74 ppg

5-1 Macondo Foamed Slurry- 16.74 ppg 5-2 5-3 5-4

6 Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS Ill

7 Macondo 9 7/8" X 7" Prod Casing - 14.17 ppg



Cum. Job Gas

Vol. Mscf

0.0 0.0 0.0 0.0 9.0

22.7 22.7 22.7 22.7 22.7

Base Slurry Vol. bbl 0.00

7.00 72.00

5.26 15.48 23.50

0.29 6.93

20.00

856.93

15

Exp. Factor

1.00 1.00 1.00 1.00 1.23 1.22 1.00 1.00 1.00 1.00

Foam Bulk Water Yield Slurry Cern. Req. Vol. bbl sk94 gal/sk94 ftS/sk94 0.00

7.00 72.00

5.26 22 4.940 1.3700 18.98 63 4.940 1.3700 28.77 96 4.940 1.3700

0.29 1 4.940 1.3700 6.93 28 4.940 1.3700

20.00

856.93


HALLIBURTON

4.0 CENTRALIZERS

4.1 Centralizer Parameters

Calculated Standoff/Spacing Profile Use Average Joint Lengths Torque and Drag Calculations Fluid Profile As Top of Plug Lands Maximum Distance between Centralizers Minimum Distance between Centralizers Calculate Standoff Above

4.2 Centralizer Specifications

Part Number Type* COD Hole Dia.

in in 8.5 BS 7.000 8.500

Nom. Dia. in 8.622

BP AMERICA PRODUCTION COMPANY Macoodo #1

Macoodo Prospect MC 252 #1 - 9.875 X 7 prod Casing

No No

183.0 ft 20.0 ft Yes

Min. Dia. Start Force

in lbf 7.625 1094

Run Rest. Bows Force Force

lbf lbf 774 1191 4

*BS- Bow Spring, R(S)- Rigid Solid, R(PB)- Rigid Positive Bar

4.3 Constant Spacing/Standoff Centralizer Intervals

Top MD Bottom MD ft ft

18035.0 18305.0 8.5

4.4 Centralizer Placement

Centralizer Measured Deviation Azimuth Number Depth

ft 0 0

1 18305.0 0.4 38.2 2 18260.0 0.5 37.5 3 18215.0 0.6 36.7 4 18170.0 0.7 36.1 5 18125.0 0.7 34.5 6 18080.0 0.7 29.4 7 18035.0 0.6 23.7

Cent. A

Restoring Force

lbf 4

12 17 20 17 12

2456

16

Required Standoff Spacing

Tension

lbf 0

1071 2343 3614 4885 6157 7263

% ft 45.0

Centralizer

8.5 8.5 8.5 8.5 8.5 8.5 8 .5

Created: April18, 2010 at 11:25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

5.0 SIMULATION

5.1 Volume and Pressure Results



Annulus fluid is heavier than casing fluid by 38 psi. Apply appropriate back pressure on casing if floating equipment does not hold properly.

5.2 Volume and Rate Calculations

Time Surface Surface Liquid Stage In Stage Out Volume In

min bbl 0.02 1 1 0.07 3.75 3 1 15.00

16.25 3 1 65.00 22.38 4 1 84.26 32.75 5 1 105.00 42.75 5 1 125.00 47.87 6 1 140.00 57.87 7 1 180.00 70.37 7 1 230.00 82.87 7 1 280.00 95.37 7 1 330.00

107.87 7 1 380.00 120.37 7 1 430.00 132.87 7 1 480.00 145.37 7 1 530.00 157.87 7 1 580.00 170.37 7 1 630.00 182.87 7 1 680.00 195.37 7 1 730.00 207.87 7 1 780.00 220.37 7 1 830.00 232.87 7 1 880.00 245.37 7 1 930.00 257.87 7 1 980.00 264.83 7 1 1007.80

17

Total Liquid Rate Total Rate Volume Out In Out

bbl bpm bpm 0.07 4.00 4.00

15.00 4.00 4.00 65.00 4.00 4.00 84.26 2.00 2.00

129.60 2.00 3.40 162.60 2.00 2.33 172.39 4.00 2.61 203.39 4.00 3.34 248.00 4.00 3.74 296.09 4.00 3.90 344.99 4.00 3.92 394.09 4.00 3.94 443.35 4.00 3.95 492.74 4.00 3.95 542.22 4.00 3.96 591.77 4.00 3.97 641.38 4.00 3.97 691.01 4.00 3.97 740.70 4.00 3.98 790.39 4.00 3.97 839.96 4.00 3.97 889.65 4.00 4 .01 939.30 4.00 3.97 988.99 4.00 3.99

1016.95 0.00 2.74


HALLIBURTON

5.3 Horsepower, Pressure, Freefall

Time Liquid Pump Surface Volume In Output Pressure

In min bbl hp psi

0.02 0.07 48.4 479 3.75 15.00 58.6 583

16.25 65.00 60.5 602 22.38 84.26 23.2 459 32.75 105.00 62.2 1255 42.75 125.00 59.1 1190 47.87 140.00 108.6 1093 57.87 180.00 87.5 878 70.37 230.00 67.2 671 82.87 280.00 56.7 564 95.37 330.00 55.3 550

107.87 380.00 54.4 541 120.37 430.00 53.8 534 132.87 480.00 53.1 528 145.37 530.00 52.6 522 157.87 580.00 52.1 517 170.37 630.00 51.7 513 182.87 680.00 55.1 547 195.37 730.00 55.7 554 207.87 780.00 55.4 551 220.37 830.00 54.0 536 232.87 880.00 40.1 394 245.37 930.00 48.8 484 257.87 980.00 77.1 772 264.83 1007.80 0.0 1433

5.4 Gas Flow Potential



Surface ECD@ ECD@ Free Fall Pressure TO Frac Zone Height

Out psi lb/gal lb/gal ft

0 14.47 14.47 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.38 14.38 0.0 0 14.43 14.43 0.0 0 14.39 14.39 0.0 0 14.40 14.40 0.0 0 14.43 14.43 0.0 0 14.44 14.44 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.45 14.45 0.0 0 14.37 14.37 0.0 0 14.50 14.50 0.0 0 14.80 14.80 0.0 0 14.69 14.69 0.0

Gas Flow Potential at Reservoir Zone Measured Depth

10.29 18200.0 ft

Based on analysis of the above outlined well conditions, this well is considered to have a SEVERE gas flow problem. Wells in this category fall into flow condition 3.

5.5 Pressure to Break Circulation - Hydrostatic Pressures

Total Depth 13466 psi Fracture Zone 13466 psi

5.6 Pressure to Break Circulation

Gel Strength Surface Pressure Total Depth Additional Fracture Zone Pressure Additional Pressure

lbf/(1 OO*ft2 ) psi psi psi 25.00 644 408 408 50.00 1288 816 816 75.00 1932 1224 1224

100.00 2576 1632 1632 200.00 5153 3264 3264

18 Created: Aprill8, 2010 at 11:25 AM


HALLIBURTON

5.7 Final Position of Stages

Stage Description

Macon do 9 7 /8" X 7" Prod Casing - 14.17 ppg 6.7 ppg Base Oil Macondo Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS Ill Macondo Foamed Slurry- 16.74 ppg Macondo Foamed Slurry - 16.7 4 ppg Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS Ill Macondo 9 7 /8" X 7" Prod Casing - 14.17 ppg



Annular Length

ft 14075.5

109.6 1954.4 213.3

1952.1

19

Casing Annular Casing Length Top MD Top MD

ft ft ft 0.0

14075.5 14185.2 16139.6

189.0 16352.9 18116.0 545.6 17570.4

17570.4 0.0

Created: April 18, 20 I 0 at II :25 AM OptiCem v6.4.8 (OC v6.4.8)

HALLIBURTON

5.8 Final Annular Fluid Density

Measured Depth Density ft lb/gal

-0.0 14.17 101.8 14.17 212.9 14.17 324.0 14.17 435.1 14.17 546.3 14.17 657.4 14.17 768.5 14.17 879.6 14.17 990.7 14.17

1101 .8 14.17 1212.9 14.17 1324.1 14.17 1435.2 14.17 1546.3 14.17 1657.4 14.17 1768.5 14.17 1879.6 14.17 1990.8 14.17 2101 .9 14.17 2213.0 14.17 2324.1 14.17 2435.2 14.17 2546.3 14.17 2657.4 14.17 2768.6 14.17 2879.7 14.17 2990.8 14.17 3101.9 14.17 3213.0 14.17 3324.1 14.17 3435.3 14.17 3546.4 14.17 3657.5 14.17 3768.6 14.17 3879.7 14.17 3990.8 14.17 4101 .9 14.17 4213.1 14.17 4324.2 14.17 4435.3 14.17 4546.4 14.17 4657.5 14.17 4768.6 14.17 4879.8 14.1 7 4990.9 14.17 5069.0 14.17 5250.4 14.17 5381.2 14.17



Quality %

20

Hydrostatic Gradient lb/gal

0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.1 7 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.1 7 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.1 7 0.00 14.17


HALLIBURTON

Measured Depth Densitv ft lb/gal

5617.6 14.17 5796.8 14.17 5976.1 14.17 6159.9 14.17 6339.2 14.17 6518.5 14.17 6697.7 14.17 6877.0 14.17 7057.0 14.17 7254.0 14.17 7443.0 14.17 7633.0 14.17 7821.0 14.17 8000.0 14.17 8191 .6 14.17 8370.9 14.17 8550.2 14.17 8729.4 14.17 8908.7 14.17 9088.0 14.17 9327.0 14.17 9506.3 14.17 9736.0 14.17 9924.6 14.17

10150.0 14.17 10342.9 14.17 10563.0 14.17 10761.2 14.17 10977.0 14.1 7 11179.4 14.17 11441 .3 14.17 11796.0 14.1 7 12113.2 14.17 12484.0 14.17 12645.3 14.17 12896.0 14.17 13123.5 14.17 13448.0 14.17 13721.0 14.17 13998.0 14.17 14123.2 6.50 14185.9 14.30 14396.0 14.30 14684.0 14.30 14950.0 14.30 15371 .1 14.30 15776.5 14.30 16141 .4 16.74 16263.0 16.74 16356.4 14.29



Qualitv %

21

Hydrostatic Gradient lb/qal

0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.1 7 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.17 0.00 14.14 0 .00 14.11 0.00 14.11 0.00 14.12 0 .00 14.12 0.00 14.13 0.00 14.13 0.00 14.13 0.00 14.15

19.50 14.17


HALLIBURTON

Measured Depth Density ft lb/gal

16729.0 14.32 17109.3 14.36 17168.0 14.36 17469.9 14.39 17680.5 14.41 17774.0 14.42 17848.5 14.42 17932.5 14.43 18043.5 14.44 18107.5 14.44 18296.8 16.74 18304.5 16.74

BP A.lVIERICA PRODUCTION COMPANY Macondo#l


Quality %

22

Hydrostatic Gradient lb/gal

19.30 14.17 19.10 14.17 19.07 14.18 18.90 14.18 18.80 14.18 18.75 14.18 18.72 14.18 18.69 14.18 18.64 14.19 18.61 14.19 0.00 14.19 0.00 14.19


HALLIBURTON

6.0 ATTACHMENTS

6.1 Fluid Positions (graph)

OptiC em Fluid Positions at Job End

g

! I

Time = 264.83 min, Volume In = 1007.80 bbl

5 10 1520 30 20 10 0

Density (lb/gal)

······~ (149~4.1) l~U~:t U6A~!:a)

MD(1VD)

10 20 30 40 50 60 Diame ter (in)



Fluids Pumped - Macondo 9 7/ R" X 7" Prod Cas ing - 14 . 17 ppg - 6 . 7 ppg Base Oi I Macondo - M a<.:o ndo 9 7 / 8 " X 7 " Prod Cas ing - 14 .3 ppg T S Ill - Macondo Foame d SJ tu·ry - I 6 . 74 ppg

---Casi ng ---Annulus

Customer: BP AMERICA PRODUCTION COMPANY Well Description: Macon~d~o~#~l ~~~~---

Job Date: 15-Apr-20 I 0 UWI:

Sales Order#: HALLIBURTON OpliCem v6.4.8 18-Apr- 10 11:10

23 Created: April 18, 20 I 0 at II :25 AM

OptiCcm v6.4.8 (OC v6.4.8)

HALLIBURTON

6.2 Circ Pressure & Density - Frac Zone (graph)

OptiC em Circulating Pressure and Density at Fracture Zone

Downhole Annular Pressure and ECD vs. Liquid Volume A I C irculating Pressw·c - A Ilydros lat ic P ressure - ~ B

14400~------------------------------------~

Fracture Pressure/ECD at 18294 ft TVD (Ref = IU 15.0

14200

I I I I 14.8

14000 Q

~ I ,-..,

j 13800 14.6 ~

. 0

14.4 § 13600l

13400 ~-C})-5----------------------~, r-CDI> ~

0)l~voir Pressurc/ECD at 18294 ft TVD (Ref = RK!

13200~1-'I..LI --,--,-----,--,...----,-~--,---.--,-----,--1

4.0

0 200 400 600 800 I 000 1200

Volume In (bbl)



Fluids Pumped CD 6 .7 ppg Base Oil Macondo

CD Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS Ill

(]) Maeondo Foamed Slurry- 16.74 ppg

W Macondo Foamed ShuTy - 16.74 ppg

@ Macondo 9 7/8" X 7" Prod Casing- 14 .3 ppg TS III

0:) Macondo 9 7/8" X 7" Prod Casing- 14.17 ppg

Customer: BP AMERICA PRODUCTION COMPANY Well Description: Macondo #I

Job Date: 15-Apr-20 10 UWI:

Sales Order#: HALLIBURTON OptiCem v6.4.8 18-Apr-10 II: 10

24 Created: April 18, 20 I 0 at II :25 AM


HALLIBURTON

6.3 Circ Pressure & Density - Res Zone (graph)

OptiC em Circulating Pressure and Density at Reservoir Zone

Downhole Annular Pressure and ECD vs. Liquid Volume

14~00 1 C icc uloting Pcc"'"c- A Hydros tati c Pressure - ~A~ B

14000

15.0

14.8

13800 ]: u cture Pressure/ ECD at 18 189 ft TVD/ (Ref = I ,-.._

i 13600 ~

14.4 c

13400~~------------------------------------------------~ 14.2

13200_+ (]Jcrvoir Prcss ure/ECD a t 18 189 ft T VD_@cf = 1~4.0

GXD Y6l

I ;'T( 13.8 13000 P J '

1 1 f I ' I I I

0 200 400 600 800 1000 1200

Volume In (bbl)

§

CD CD CD CD CD (j)

BP AMERICA PRODUCTION COMPA" t Macondo #I

Macondo Prospect MC 252 #I - 9.875 X 7 prod Casing

Fluids Pumped 6.7 ppg Base Oil Macondo

Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS Iff

Macondo Foamed Slurry - 16.74 ppg

Macondo Foamed Slurry - 16.74 ppg

Macondo 9 7/8" X 7" Prod Casing- 14.3 ppg TS III

Macondo 9 7/8" X 7" Prod Casing- 14.17 ppg

Customer: BP AMERICA PRODUCTION COMPANY Well Description: M acondo # 1


Sales Order#: HALLIBURTON OptiCe m v6.4.8 18- Apr- 1 0 I I : I 0

25 Created: April 18,2010 at 11:25 AM


HALLIBURTON BP AMERJCA PRODUCTION COMPANY Macondo #1


6.4 Downhole Pressure Profiles (graph)

OptiC em Downhole Pressure Profiles

Minimum Hydrostatic Pressure and Maximum ECD vs. TVD (Ref = RKB) j Po re Press urc Grad i cnt Fracture Grad i c nt ....::::::::::=::._ __ __:::::::::::::::::: __ :::;:::::::::::-Minimum Hydrostat ic Gradie nt Maximum ECD ------------------

1

17500~ ~ @ 17750

18000

18250

1 8500,~'~--------~~--~--~~----~---------------------------.----~-----13.8 15.0 14.0 14.2 14.4

ECD (lb/gal) 14.6 14.8

C u stomer: BP AMERICA PRODUCTION COMPANY Well Description: Macondo # 1

26


Sales Order#: HALLIBURTON OptiCem v6.4.8 I 8 -Apr-1 0 I I: I 0



Macondo Prospect MC 252 #I - 9.875 X 7 prod Casing

6.5 MC252#1_BP01_Svy_Rec_NO_ 4_10_10.txt (text)

#VERS. #WRAP.

1. 20: NO:

Halliburton Ascii file One line per depth step

-Well Information Block #MNEM.UNIT Data Type Information #--------- -----------

STRT.F STOP.F STEP . F NULL . WN CN RIG FN CNTY . STAT . CTRY. SRVC. LEAS. DCON. SECT . TOWN. RANG. SON APIN . DOE LUNO . COLG. CULG. REGN. DIST. JOBN. MWDS. Plat. Pad . Slot. Bloc. Sub . SPUD. GCDE . GPMT. GREF. GGSY . LLGR . CCDE. CPJM. CREF . CGSY . XYGR . MDS MMDL. Mag DFWT . DFST.

5067. 0000 : START DEPTH 18360 .0000: STOP DEPTH

0 . 0000 : STEP DEPTH - 999.2500 : NULL VALUE WELL NAME : OCS - G 32306 001 ST00BP01

CUSTOMER NAME: BP Exploration and Production RIG NAME : Deepwater Horizon

FIELD NAME : Mississippi Canyon Blk. 252 COUNTY NAME:

STATE NAME : Louisiana COUNTRY NAME: U.S . A/Offshore LA

CONTRACTOR: LEASE NAME : Macondo Prospect

DIRECTNL CONTR : Sperry SECTION :

TOWNSHIP : RANGE:

JOB NUMBER : LA-MM-0007026939 API S/N : 608174116900

DOE NUMBER: UNIT NUMBER: 82418

COMPANY LOGO: CUSTOMER LOGO:

REGION: Central DISTRICT: Broussard, LA

JOB TICKET NUMB: 7026939 MWD SHOP: South PLATFORM:

PAD: SLOT :

BLOCK : 252 SUB BLOCK: SPUD DATE : 16 : 14:56 06- 0ct-09

GEO COORD DESC : GEO PROJ METHOD:

GEO REFERENCE: GEO GRID SYS :

LLGROUP : CART COORD DESC: CART PROJ METRO :

CART REFERENCE: CART GRID SYS :

XYGROUP: MAG DATA SOURCE : Operator Entered

MAGNETIC MODEL : MAG DATA DATE: DIST FWL TEXT : DIST FSL TEXT:

27 Created: April 18, 2010 at 11 :25 AM




PDAT. LMF DMF . RC ETIM. DMOD . SVYD. !LTD . FTOP . RCST . $/da AGAP. ft CMER.deg VSNS.ft VSEW. ft LATI.deg LONG . deg EKB .ft EDF . ft TVDS . ft EGL . ft WDMS . ft WHNS . ft WHEW . ft UTMX . m UTMY.m DFWL.ft DFSL . ft EPD . ft APD .ft STRD.ft

PERMANENT DATUM: LOG MEAS FROM:

DRILL MEAS FROM: START TIME:

END TIME: DRILL MOD DESC :

SURVEY DESC : INTERP LTH DESC :

FORM TOPS DESC: RIG COST :

AIR GAP : CENTRL MERIDIAN:

VERT SEC N/S: VERT SEC E/W:

LATITUDE: LONGITUDE :

KB ELEV: OF ELEV :

TVDSS CORRECTN: GL ELEV: WD ELEV :

WELL HEAD N/S : WELL HEAD E/W :

UTM X: UTM Y:

DISTANCE FWL : DISTANCE FSL:

ELEVATION: DEPTH ABOVE PO:

START DEPTH:

Mean Sea Level Drill Floor Drill Floor 16:14:56 06-0ct- 09 10 : 59:12 12- Apr-10 Drill Model Survey Lithology Formation Tops 0.000000 75.000000 0 . 000000 0.000000 0 . 000000 28 . 738138 -88.365944 0 . 000000 75 . 000000 75.000000 0.000000 4992 . 000000 0 . 000000 0.000000 366612.937500 3179557.750000 0 . 000000 0 . 000000 0 . 000000 75.000000 5067 . 000000

EDEP.ft END DEPTH: 18260.000000 VSDR . deg VERT SEC DIRECT : 256 .640015 MFLD.nT MAGNETIC FIELD: 47321.000000 MDIP.deg MAGNETIC DIP: 58 . 613998 GVFD.g GRAVITY FIELD : 1.000000 MDEC.deg MAGNETIC DECL: - 0 . 945000 GRDC.deg GRID CORRECTION: -0 . 656900 AZTC.deg AZM TOTAL CORR: - 0 . 288100 WTYP. WELL TYPE : 0 VSC . VS TO CLOSURE: 0 MAGU. MAGUTM CHECKSUM: 1710684 NREF. NORTH REFERENCE: 2 HPTY. HOLE POS TYPE: 0

#------- -OTHER INFORMATION SECTION ----------------#-START CURVE INFORMATION XML-#<xml version = "1 " missingfloat = " -999.2500" missinginteger = " -999" missingascii = "" > # <curve name = " Dept h " wellname = "" run = "" record = "" description = '"' unit = "ft" unittype = " Dept h " format = " F" size = "8" specialbits decimalplaces = "3" optionliststring = "false" > </curve> # <curve name = " Inclination" wellname = " MC252 BP01 " run = "Descriptor_run" record = " Survey" description = "Descriptor_ data" unit "deg" unittype = "Hole angle " format = "F" size = "4 " specialbits = "C" decimalplaces = " 2 " optionlis t string = "false" > </curve> # <curve name = "Azimuth" wellname = "MC252 BPOl" run "Descriptor run" record = "Survey" description

28 " Descriptor data" unit =




"deg" unittype = " Hole angle" format = "F" size = " 4" specialbits = "C" decimalplaces = " 2 " optionl i ststr i ng = " false" > </curve> # <curve name = " TVD" wellname = "MC252 BP01 " run = " Descriptor_run" record = "Survey" description = "Descriptor_data" unit = "ft" unittype "Depth" format = "F" size = "4" specialbits = " C" decimalplaces = "2" optionliststring = "false" > </curve> # <curve name = "N/S Departure " wellname = " MC252 BP01 " run " Descriptor_ run" record = "Survey" description = "Descriptor_data" unit " ft" unittype = "Depth" format = " F" size = "4" specialbits = "C" decimalplaces = " 2 " optionliststr i ng = ''false " > </curve> # <curve name = "E/W Departure " wellname = " MC252 BP01" run " Descriptor_run" record = " Survey" description = "Descriptor_data" unit " ft " unittype = " Depth" format = "F" size = "4" specialbi t s = "C" decimalplaces = " 2" optionliststring = "false " > </curve> # <curve name = "Vertical Sec " wellname = " MC252 BP01" run " Descriptor_run" r ecord = " Survey" description = "Descriptor_data" unit "ft" unittype = " Depth" f ormat = "F" size = " 4 " specialbits = "C" decimalplaces = "2" optionliststring = "false " > </curve> # <curve name = "DogLeg Seve rity" wellname = "MC252 BP01" run "Descriptor run" r ecord = " Survey" description = " Descriptor data " unit " °/100' " unittype ="Dogleg severity" format "F"-size = "4" specialbits = "C" decimalp l aces = " 4" optionliststring = "false" > </curve> #</xml> #-END CURVE INFORMATION XML# #------- CURVES MNEMONICS -----------------# DEPT Inclinatio Azimuth Latitude Departure VerticalSe #------- CURVES UNI TS ---------------------# ft deg deg ft ft ft

5067 . 0000 0 . 00 0.00 0.00 0.00

5526.0000 1. 96 -1. 55 7.70 -7. 13

5621.0000 1. 65 -2.0 4 10.64 -9.88

5719 . 0000 1. 34 -2.36 13 . 18 - 12.28

5815.0000 1.13 -2 .51 15.24 - 14.25

5908.0000 0.94 -2.58 16 .92 - 15.87

6004.0000 0.86 -2.66 18 . 43 -17 . 31

6099.0000 0. 72 - 2 . 68 19 . 74 - 18.58

6195 . 0000 0.61 - 2 . 65 20 . 85 -19.67

6304.0000 0 . 49 -2.56 21.89 - 20.71

6401.0000 0 . 09 -2.50 22.38 -21.20

6495.0000 0 . 03 -2.50 22 . 47 -21.29

29

TVD DogLeg

ft 0 /100 '

0 . 00 5067.00 0.00

101 . 40 5525 . 91 0.43

97.18 5620 . 86 0 . 35

96 . 79 5718 . 83 0 .32

91.44 5814 . 81 0 . 25

93.43 5907.79 0 . 21

92.56 6003 . 78 0.08

89 .32 6098.77 0.15

86.62 6194 . 76 0 . 12

83 . 25 6303.76 0 . 11

82 . 22 6400 . 76 0.41

119 .73 6494.76 0 . 07




6590 . 0000 0.03 211. 60 6589.76 -2.54 22.48 -21.29 0.05

6685 . 0000 0 .03 318.07 6684 . 76 -2.54 22.45 -21.26 0 .05

6780 . 0000 0 . 09 42.64 6779.76 - 2 . 46 22 . 49 -21.31 0 . 10

6873 . 00 00 0 . 10 268 . 01 6872.76 -2 . 41 22.45 - 21.29 0 . 19

6971 .0000 0.12 300.37 6970.76 -2 . 36 22.28 -21.13 0 . 07

7057 . 0000 0 .03 100 . 60 7056 .76 -2.32 22.23 -21.09 0.17

7159.0000 0 . 04 240.74 7158 . 76 -2 . 35 22.22 - 21.08 0 . 06

7254 . 0000 0 .03 220.74 7253 . 76 -2 . 38 22 . 18 -21.03 0 . 02

7350 .0000 0.04 273.74 7349 . 76 -2 . 40 22.13 -20 . 97 0 . 03

7443 . 0000 0 . 06 135 . 02 7442 . 76 -2 . 43 22.13 - 20 . 97 0 . 10

7538.0000 0 . 06 171. 62 7537 . 76 -2.51 22.17 - 20.99 0.04

7633 . 0000 0 . 04 333 . 42 7632 . 76 - 2 . 53 22.16 -20.98 0 . 10

7727.0 00 0 0.00 359.77 7726 .7 6 -2. 50 22.15 -20.97 0.04

7821 . 0000 0 . 03 335.23 7820.76 - 2 . 48 22 .14 -20.96 0.03

792 1 .0000 0.12 180 . 97 7920.76 - 2 .56 22.12 -20 . 93 0.15

8000 . 0000 1. 06 19 . 95 7999 . 75 -1.96 22.37 -21.31 1. 49

8096 . 0000 0.94 17.01 8095 .7 4 -0.37 22 . 91 - 22.20 0.14

8192 .000 0 0.03 16.08 8191.73 0 . 41 23.14 -22 . 61 0 . 95

8289.0000 0 . 23 225 . 81 8288 . 73 0 . 29 23.01 -22.46 0 . 26

8382 . 0000 0 . 06 34 . 14 8381.73 0 . 20 22 . 90 - 22 . 33 0 . 31

8477 . 0000 0 . 06 324 . 47 8476 . 73 0 . 29 22.90 -22. 35 0 . 07

8573 . 0000 0.09 9.44 8572 . 73 0 . 40 22 . 89 -22.36 0 . 07

8667.0000 0 . 09 46 . 61 8666 . 73 0.53 22 . 95 - 22.45 0 . 06

8762.0000 0.06 86 . 68 8761 . 73 0 . 58 23 . 06 - 22 . 57 0 . 06

8854 . 0000 0 . 09 9 . 44 8853 . 73 0 . 65 23.12 -2 2 . 64 0.10

891 7.0000 0 . 06 46.61 8916 . 73 0 . 73 23.15 - 22 . 69 0 . 09

9187 . 0000 2 . 47 1 06 . 30 9186.65 -0.81 28 . 84 -27 . 87 0.90

9327 . 0000 0 . 44 96 . 00 9326 . 60 -1 . 7 1 32 . 27 -31.00 1. 46





9463 . 0000 0.38 90 . 85 9462.59 -1 . 78 33 . 24 -31.93 0 . 05

9603.0000 0.45 125 . 67 9602 . 59 -2 . 1 0 34 . 15 - 32.74 0 . 18

97 36 . 0000 0.38 153.99 9735.59 -2 . 80 3 4 . 76 - 33.18 0 . 16

9874 . 0000 0 .39 1 41.03 9873 . 58 - 3 . 58 35. 26 -33.48 0 . 06

10004. 0000 0.25 157 . 87 10003 . 58 - 4.19 35 . 65 -33 . 71 0 . 13

10150 . 000 0 0 . 36 162 . 34 10149 . 58 -4 . 92 35. 91 -33.80 0 . 08

10285 . 0000 0.44 184 . 5 0 10284.58 -5 . 84 35.99 -33 . 67 0.13

10424 . 0000 0 . 47 182.69 10423.57 -6.94 35 . 92 - 33.35 0.02

10563 . 0000 0 . 47 210 . 58 10562 . 57 -8 . 00 35 . 61 - 32.80 0.16

10701 . 0000 0 . 47 205 . 53 10700 .56 -9 . 00 35 . 08 -32.05 0 . 03

1 0839 . 0000 0 . 47 208 . 48 10838.56 -10.01 34.56 -31 . 31 0 . 02

10 977 . 0000 0.56 204 . 08 10976.55 - 11. 12 34 . 02 -30 . 53 0 . 07

11114 . 000 0 0 . 67 205 . 50 11113 . 54 - 12 . 46 33 . 40 - 29 . 62 0. 08

11252 . 0000 0 . 61 216 . 24 11251 . 54 - 13.78 32 . 62 -28.55 0 . 10

11390.0000 0 . 50 220.53 11389 . 53 -14.83 31. 79 - 27.51 0 . 09

11528.0000 0 . 45 191.93 1152 7 .52 -1 5. 81 31. 29 - 26.79 0 . 17

11665 . 0000 0 . 38 185 . 19 11664 . 52 -16 . 79 31. 14 - 26 . 41 0.06

11796 . 0000 3.15 267 . 85 11 795.45 -17 . 36 27 . 50 - 22 . 75 2 . 38

11934 . 0000 5. 62 264 . 12 11933.04 -18 .20 1 6 . 99 -12.33 1. 80

12070 . 0000 9.13 264 . 29 12067 . 89 - 19.95 - 0 . 38 4 . 98 2 . 58

12209 . 0000 9.94 262 . 27 12204 . 97 -22.67 - 23 . 24 27 . 85 0 . 63

12347. 0000 9.22 2 62 . 55 12341 . 04 - 25.70 - 4 6 . 01 50 . 70 0.52

1 2 484 . 0000 8.62 263. 43 12476.39 - 28 . 30 -67 . 09 71 . 81 0.4 5

12622 . 0000 7.25 261. 10 12613 .06 - 30.83 - 85.96 90 . 76 1. 02

12760 . 0000 5.99 261.62 12750.1 4 - 33 . 23 - 101.69 106 . 62 0.91

12896 . 0000 4.33 261.99 12885 . 58 - 34.98 - 113 . 80 118 . 80 1. 22

1 3034 . 0000 1. 29 264 . 67 13023 . 40 - 35.85 - 120 . 51 125 . 53 2. 21

1311 2. 0000 0.67 257 . 80 13101 . 39 - 36 . 03 -12 1 . 83 126 . 86 0 . 8 1

31 Created: April 18, 20 I 0 at 11 :25 AM




13172.0000 0 .62 261.38 13161.39 -36 . 15 -122.49 12 7 . 53 0.11

13310.0000 0.89 272 . 3 9 13299 . 38 -36 . 21 -124 .30 129 . 30 0 . 22

13448 . 0000 0 . 64 276 . 61 13437 . 36 -36.08 -126 . 14 131.06 0 .18

13585 . 0000 0.62 274.81 13574.35 -35.93 -127.64 132 . 4 9 0 . 02

13721 . 0000 0 . 68 267 . 45 13710 . 35 -35.90 -129.19 133 . 99 0 . 08

13859 . 0000 0 . 69 273 . 76 13848 . 34 -35.89 - 130.84 135.59 0 . 06

13998 .0000 0.80 265 . 26 13987 . 32 -35 . 91 -132 . 65 137 . 35 0 . 11

1 4133 . 0000 0 . 56 274 . 17 14122 . 31 -35 . 94 - 134 . 25 138 . 92 0 . 20

14273.0000 0 . 80 262 . 37 14262 . 30 -36 . 02 - 135 . 90 140 . 55 0 . 20

14549 . 0000 0 . 47 291.13 14538 . 29 -35 . 87 - 138 . 88 14 3 .4 1 0 . 16

14684.0000 0 . 31 268 .6 9 14673 . 28 -35.68 -139 . 76 144.22 0 . 16

14816 . 0000 0 . 66 235 .3 9 14805 . 28 -36 . 12 -140.74 145.28 0 . 33

14950 . 0000 0.70 230 . 44 14939.27 -37 . 08 - 142 . 00 146 . 73 0 . 06

15081 . 0000 0. 64 241.45 15070 . 26 - 37 . 94 -1 43.27 148 . 16 0.11

15264.0000 0.67 214 . 46 15253 . 25 -39.31 -144.78 149 . 95 0 .1 7

15406.0000 0 . 74 228 .4 1 153 95 . 24 -40 . 61 -145 . 94 151 . 37 0. 1 3

15540.0000 0 . 69 223 . 80 15529.23 -41 . 77 - 147 . 14 152 . 81 0 . 06

15673.0000 0 . 57 242.79 15662 . 22 -42 . 65 -148.28 154.13 0 .18

15805 . 0000 0 . 59 234 . 90 15794 . 21 -43 . 33 - 149.42 155.39 0.06

15939 . 0000 0.75 246.89 15928 . 21 - 44 . 07 - 150 . 78 156.89 0 . 16

16072 . 0000 0 . 87 240.57 16061. 19 -44 . 91 -152 . 47 1 5 8 . 72 0.11

16204 . 0000 0.70 235 . 12 161 93 . 18 - 45.87 - 154 . 01 160 . 44 0 . 14

16333 . 0000 0.68 229 . 09 16322.17 -46 .82 - 155 . 23 161.85 0 . 06

16470.0000 0 . 78 235 . 12 16459 . 16 -47 . 88 - 156 . 61 163 . 44 0 . 09

16604 . 0000 0 . 87 222.16 16593 . 14 -49 . 16 - 158 . 05 165.13 0 . 16

16729.0000 0.78 224.22 16718.13 -50.48 - 159 . 28 166.63 0.08

16870 . 0000 0 . 81 233 . 89 1685 9 .12 -51.76 - 160 . 76 168.36 0.10

17004 . 0000 0.67 206 . 18 16993.11 - 53 .01 - 161.87 169 . 74 0 . 28



HALLIBURTON

17136.0000 0 . 92 -54 . 51 -162.88

17318.0000 0.64 -56.65 - 163.74

17455.0000 0 . 36 -57.84 -163 . 74

17592.0000 0.31 -58 . 62 - 163 . 65

17728.000 0 0.38 - 58 . 82 - 163 . 09

17867.0000 0 . 38 -58.28 -162.42

18003 . 0000 0 . 62 -57.21 -161.94

18138 . 0000 0. 74 -55.81 -161.18

18348 . 0000 0.38 -54.16 -159.96

18360.0000 0.38 -54.10 -159 . 91



171.07

172 .40

172.67

172.77

172 . 27

171.49

170.77

169.72

168.15

168 . 08

33

219.94 17125.09 0.24

175.50 17307 . 08 0.35

187.90 17444 . 07 0.22

157.69 17581.07 0.13

70.52 17717 . 07 0.35

32.17 17856.07 0.18

19.34 17992 . 06 0.20

35.87 18127 . 05 0 . 17

38.20 18337 . 04 0 . 18

38 .20 1834 9 . 04 0.04


HALLIBURTON

Bp America Prod Co-soraclgom Ebiz PO Box 22024 • Do Not Mail Tulsa, Oklahoma 74121-2024

Macondo 1 MISSISSIPPI CANYON Blk: 252

United States of America

9 7/8" X 7" Production Casing

Prepared for: Brian Morel

April18, 2010 Version: 6

Submitted by: Jesse Gagliano Halliburton 1 0200 Bellaire Blvd Houston, Texas 77072-5299

1/12

HALLIBURTON

Proposal Macondo_MC 252_ 9 7/8" X 7" Prod Casing_ v.6

HALLIBURTON

Foreword

Halliburton appreciates the opportunity to present this proposal and looks forward to being of service to you.

Enclosed is our recommended procedure for cementing the casing strings in the referenced well. The information in this proposal includes well data, calculations, materials requirements, and cost estimates. This proposal is based on information from our field personnel and previous cementing services in the area.

Halliburton Energy Services recognizes the importance of meeting society's needs for health, safety, and protection of the environment. It is our intention to proactively work with employees, customers, the public, governments, and others to use natural resources in an environmentally sound manner while protecting the health, safety, and environmental processes while supplying high quality products and services to our customers.

We appreciate the opportunity to present this proposal for your consideration and we look forward to being of service to you. Our Services for your well will be coordinated through the Service Center listed below. If you require any additional information or additional designs, please feel free to contact myself or our field representative listed below.

Prepared and Submitted by:

SERVICE CENTER:

Jesse Gagliano Technical Advisor

Lafayette, La

SERVICE COORDINATOR: Danny Mooney Y arigsa Aviles 1-800-444-7830

OPER. ENGINEER: PHONE NUMBER:

2/12 Proposal Macondo_MC 252_ 9 7/8" X 7" Prod Casing_ v.6

HALLIBURTON

Job Information

Well Name: Macondo

Riser Outer Diameter Inner Diameter

16" Casing Outer Diameter Inner Diameter Linear Weight

13 5/8" Liner Outer Diameter Inner Diameter Linear Weight

11 7 /8" Liner Outer Diameter Inner Diameter Linear Weight

9 7/8" Liner Outer Diameter Inner Diameter Linear Weight

10 112" Average Hole Size Inner Diameter Job Excess

8.88" Average Hole Size Inner Diameter Job Excess

6 5/8" Drill Pipe Outer Diameter Inner Diameter Linear Weight

9 7/8" Casing Outer Diameter Inner Diameter Linear Weight

7" Production Casing Outer Diameter Inner Diameter Linear Weight

3 I 12

9 7/8" X 7" Production Casing

Well#: 1

0 - 5067 ft (MD) 24.000 in 19.500 in

5067- 11585 ft (MD) 16.000 in 14.920 in 97lbm/ft

11185-13100 ft(MD) 13.625 in 12.375 in 88.20 lbm/ft

12816- 15113 ft (MD) 11.875 in 10.711 in 71.80 lbm/ft

14803- 17163 ft (MD) 9.875 in 8.625 in 62.80 lbm/ft

17163- 18130 ft (MD) 10.500 in 0%

18130-l8304ft(MD) 8.880 in 0%

0 - 5067 ft (MD) 6.625 in 5.291 in 40.0 l lbm/ft

5067 - 12485 ft (MD) 9.875 in 8.598 in 62.80 1bm/ft

12485- 18304 ft (MD) 7.000 in 6.143 in 32lbm/ft


HALLIBURTON Water Depth Air Gap

Mud Type Mud Weight BHST BHCT

4 I 12

4992 feet 75 feet

Synthetic 14 Ibm/gal 210 degF 210 degF


HALLIBURTON ---------------

Calculations

Mud: (110.00 ft fill)

Spacer:

110.00 ft * 0.3585 if/ft * 0% Total Mud

88.00 ft * 0.3585 ft3/ft * 0% 310.00 ft * 0.1385 ft3/ft * 0% 2050.00 ft * 0.1385 ft3/ft * 0% 137.00 ft * 0.3341 iflft * 0% Total Spacer

Cement: (100.00 ft fill) 100.00 ft * 0.3341 ft3/ft * 0% Total Lead Cement

Sacks of Cement

Cement : (904.00 ft fill) 730.00 ft * 0.3341 ft3/ft * 0% 174.00 ft * 0.1628 iflft * 0% Foamed Tail Cement

Shoe Joint Volume: (189.00 ft fill) 189.00 ft * 0.2058 ft3/ft

Tail plus shoe joint

Total Tail

Total Pipe Capacity: 5067.00 ft * 0.1527 ft3/ft 7418.00 ft * 0.4032 ft3/ft 5819.00 ft * 0.2058 ft3/ft

Displacement Volume to Shoe Joint: Capacity of Pipe - Shoe Joint

5 I 12

9 718" X 7" Production Casing

= 39.43 ft3

= 39.30 ft3

= 7.00 bbl

= 31.55 ft3

= 42.93 ft3

= 283.89 fe = 45.77 ft3

= 404.25 if = 72.00 bbl

= 33.41 ft3

= 33.41 ft3

= 5.95 bbl = 24 sks

= 243.87 if = 28.33 ft3

= 272.20 if = 48.48 bbl

= 38.90 if = 6.93 bbl = 311.10 if = 55.41 bbl

191 sks

= 773.67 if = 2990.95 if = 1197.67ft> = 883.82 bbl

= 883.82 bbl - 6.93 bbl = 876.89 bbl


HALLIBURTON

Job Recommendation 9 718" X 7" Production Casing

Fluid Instructions Fluid 1: Mud Base Oil

Fluid 2: Water Based Spacer TUNED SPACER ITI

0.6 gallbbl 0.6 gallbbl 0.6 gal/bbl llbm/bbl

Dual Spacer Surfactant A (Additive Material) Dual Spacer Surfactant B (Additive Material) SEM-8 (Additive Material) WellLife 734 (Additive Material)

Fluid 3: Lead Cement- Un-foamed Premium Cement

94 lbm/sk Premium Cement (Cement)

Fluid Density: Volume Behind:

Fluid Density: Fluid Volume:

Fluid Weight Slurry Yield:

0.07% Halliburton EZ-FLO (Bulk Flow Enhancer) 0.25% D-AIR 3000 (Defoamer)

Total Mixing Fluid:

1.88 lbm/sk KCL (Additive Material) 20 % SSA-1 (Additive Material) 15% Common White-100 Mesh, SSA-2 0.2 lbm/sk SA-541 (Additive Material) 0.11 Gal/sk Zonesealant 2000 (Foamer) 0.09 Gal/sk SCR-lOOL (Retarder)

Top of Fluid: Calculated Fill:

Volume: Calculated Sacks:

Proposed Sacks:

6.70 Ibm/gal 7 bbl

14.30 Ibm/gal 72 bbl

16.74 Ibm/gal 1.37 ~/sk 5.04 Gal/sk 17300 ft 100ft 5.95 bbl 24.37 sks 30 sks

l lbm/bbl WellLife 734 (Additive Material)- added by band to down bole side

Fluid 4: Foamed Tail Cement- Foamed to average density of 14.5 ppg Premium Cement Fluid Weight

94 lbm/sk Premium Cement (Cement) Slurry Yield: 0.07% Halliburton EZ-FLO (Bulk Flow Enhancer) Total Mixing Fluid: 0.25 % D-AIR 3000 (Defoamer) Top of Fluid: 1.88 lbm/sk KCL (Additive Material) Calculated Fill: 20% SSA-1 (Additive Material) Volume:

16.74 lbm/gal 1.37 ~/sk 5.04 Gal/sk 17400 ft 904ft 55.41 bbl

15% Common White-100 Mesh, SSA-2 Calculated Sacks: 191.44 sks 0.2 lbm/sk SA-541 (Additive Material) Proposed Sacks: 200 sks 0.11 Gal/sk Zonesealant 2000 (Foamer) 0.09 Gal/sk SCR-lOOL (Retarder) l lbmlbbl WeULife 734 (Additive Material)- added by hand to down hole side

6/l2 Proposal Macondo_MC 252_ 9 7/8" X 7" Prod Casing_ v.6

HALLIBURTON Fluid 5: Water Based Spacer TUNED SPACER ill

0.6 gallbbl 0.6 gal/bbl 0.6 gallbbl

Fluid 6: Mud Mud

Dual Spacer Surfactant A (Additive Material) Dual Spacer Surfactant B (Additive Material) SEM-8 (Additive Material)

Fluid Density: Fluid Volume:

Fluid Density: Fluid Volume

14.30 lbmlgal 20 bbl

14lbmlgal 856.89 bbl


HALLIBURTON

Job Procedure 9 718" X 7" Production Casing

Detailed Pumping Schedule

Fluid# Fluid Fluid Name Surface Type Density

Ibm/gal

1 Mud Base Oil 6.7

2 Spacer TUNED SPACER III 14.3

3 Cement Cap Cement 16.7

4 Cement Foamed Tail 16.7

5 Spacer TUNED SPACER ill 14.3

6 Mud Mud 14.0

Foam Output Parameter Summary: Fluid# Fluid Name Un-foamed Beginning

Liquid Density Volume Ibm/gal

Stage 1

4 Foamed Tail 39.82bbl 14.5

Foam Design Specifications: Foam Calculation Method: Constant Gas Flow

Backpressure: 14.70 psig Bottom Hole Circulating Temp: 210 degF

Mud Outlet Temperature: 150 degF

Estimated AvgRate bbVmin

4.0

4.0

2.0

2.0

4.0

4.0

Ending Density Ibm/gal

14.5

Downhole Volume

7 bbl

72 bbl

30 sks

200 sks

20 bbl

856.89 bbl

Beginning Ending Rate Rate

scf!bbl scflbbl

521.1 521.1

Calculated Gas= 20748.4 scf Additional Gas = 50000 scf

Total Gas= 70748.4 scf

Hold Safety Meeting with all personnel to discuss foam cementing operations and possible hazards.

1. ONCE LANDED OUT WITH 9.875" x 7"CASING RIG UP HALLIBURTON AND NITROGEN LINES TO CEMENT STAND.

2. WITH RIG PUMPS, PUMP AND CIRCULATE 111 BBLS@ l BPM. NEXT, CIRCULATE 150 BBLS @ 4 BPM AS PER CO.MAN.

3. WHILE CIRCULATING, NITROGEN UNIT SHOULD BE COOLED DOWN, AND NITROGEN LINES WILL BE TESTED TO 5000 PSI.

4. ONCE CIRCULATING IS COMPLETE, CLOSE TOP TIW AND PUT 500 PSI ON TOP DRIVE. MAKE SURE THAT BOTTOM TIW VALVE IS OPEN.

5. WITH HALLIBURTON UNIT PUMP 7 BBLS OF 6.7 PPG BASE OIL@ 4 BPM.

6. WITH HALLIBURTON UNIT PUMP 10 BBLS OF 14.3 PPG TUNED SPACER @ 4 BPM.

7. CLOSE THE 2" LO-TORC VALVE ON THE CEMENT STAND. MAKE SURE RIG FLOOR IS CLEAR OF ALL PERSONAL. TEST CEMENT LINES TO 5000 PSI.


HALLIBURTON 8. ONCE ALL TEST ARE COMPLETE MAKE SURE PRESSURE HAS BEEN RELEASED AND

OPEN THE 2" LO-TORC VALVE.

9. PUMP 62 BBLS OF 14.3 PPG TUNED SPACER AT 4 BPM.

10. SHUT DOWN, WASH OUT MEASURING TANKS ON CEMENT UNIT, AND WEIGH UP CEMENT.

11. MIX AND PUMP 4 BBLS OF UNFOAMED LEAD CEMENT AT 16.74 PPG. PUMP RATE OF 2 BPM.

12. DROP DART TO RELEASE BOTTOM PLUG.

13. MIX AND PUMP 4 BBLS OF UNFOAMED LEAD CEMENT AT 16.74 PPG. PUMP RATE OF 4 BPM.

14. BRING NITROGEN ONLINE

15. MIX AND PUMP 39 BBLS OF FOAMED TAIL CEMENT AT 14.5 PPG AFTER FOAMING. PUMP RATE OF 2 BPM. (FOAM VOLUME OF 48 BBLS).

16. BRING NITROGEN OFF LINE

17. MIX AND PUMP 4 BBLS OF UNFOAMED SHOE CEMENT AT 16.74 PPG. PUMP RATE OF 2 BPM.

18. PUMP 3 BBLS OF 14.3 PPG TUNED SPACER@ 2 BPM.

19. DROP DART TO RELEASE TOP PLUG.

20. PUMP 17 BBLS OF 14.3 PPG TUNED SPACER AT 4 BPM.

21. WITH HALLIDURTON PUMPS DISPLACE CEMENT WITH 130 BBLS OF 14.0 PPG MUD @ 4 BPM.

22. REZERO, AND PUMP 727 BBLS OF 14.0 PPG MUD WITH RIG PUMPS @ 4 BPM. IF PLUG DOES NOT BUMP, PUMP NO MORE THAN AN ADDITIONAL 17 BBLS FOR A TOTAL OF 744 BBLS WITH RIG PUMPS.

23. BUMP PLUG AND PRESSURE UP TO 500 PSI ABOVE CIRCULATING PRESSURE. CHECK FLOATS AND BLEED BACK NO MORE THAN 6 BBLS. IF 6 BBLS ARE BLED BACK TO THE UNIT, PUMP AN ADDITIONAL 6 BLS OF 14.0 PPG MUD AND HOLD PRESSURE. TIME TO BE DECIDED BY BP COMPANY REPS AND ENGINEERS.

24. SET SEAL ASSEMBLY AND RELEASE RUNNING TOOL FROM HANGER.

25. PULL 2 STDS AND DROP DRILL PIPE NERF BALL. PUMP 1 Yz DRILL PIPE VOLUME (+/-207 BBLS).

26. POOH.

9 I 12 Proposal Macondo_MC 252_ 9 7/8" X 7" Prod Casing_ v.6

HALLIBURTON Cost Estimate 9 7/8" X 7" Production Casing

SAP Quote# 0 Mtrl Nbr DescriJ!tion Q!y U/M Unit Price Net Amt

7523 CMT PRODUCTION CASING BOM 1 JOB 0.00 ***Spacer Material***

483826 TUNED SPACER III 92 BBL 122.28 11,249.76 100003664 DUAL SPACER SURFACTANT A 56 GAL 91.32 5,113.92 100003665 DUAL SPACER SURF. B 56 GAL 42.88 2,401.28

101235090 SEM-8 56 GAL 47.45 2,657.20 101492086 WELLLIFEz. 734 118 LB 4.10 483.80

***Cement Material*** 100003687 PREMIUM CEMENT 230 SK 14.72 3,385.60 1010023 14 EZ-FLO 16 LB 10.57 169.12 101007446 D-AIR3000 55 LB 4.31 237.05 100001585 KCL POTASSIUM CHLORIDE 433 LB 0.55 238.15

100003691 SAND-200 MESH SILICA FLOUR SSA-1 4324 LB 0.24 1,037.76

100003676 SAND-COMMON WHITE-100 MESH, SSA-2 33 SK 24.28 801.24

100009911 SA-541 SUSPENDING AID- 46 LB 13.20 607.20

101207218 ZONESEALANT 2000 26 GAL 77.25 2,008.50

100012238 SCR-100 L 21 GAL 76.65 1,609.65 ***Personnel***

130443 ZONESEAL CERTIFIED SPECIALIST H/DA Y/MO 1 H 145.24 13,943.04 TOTAL NUMBER 96 HRIDA Y /WEEK/MTHNEAR/JOB/RUN

576784 CMT, Offshore Engineer, per hr 1 EA 134.32 12,894.72 HOURS 96

***Equipment*** 583768 CMT,Foam Cmt Base Rate(3-day)-SORAC 1 EA 24,295.68 24,295.68 583769 CMT,Addl Day Foam Cmt Day Rate-SORAC 5 DAY 3, 100.45 15,502.25

Total USD 98,635.92


HALLIBURTON

SAP Quote#O Mtrl Nbr Descril!tion .Q!y U/M Unit Price NetAmt

342210 N2 BOM-Foam Cementing w/o CT 1 JOB 0.00 13459 Nitrogen Charge 70748 SCF 6.60 4,669.37

***Personnel*** 576758 CMT, Equipment Optr, per hr 2 EA 46.62 8,951.04

HOURS 96 ***Equipment***

583772 CMT,N2 Base Rate(3day)Foam Cmt Job-SORAC 1 EA 31,745.54 31,745.54 583773 CMT,Addl N2 Day Rate Foam Cmt Job-SORAC 5 DAY 8,056.40 40,282.00 583837 CMT,Addll OOft N2 Iron, ZI Foamed-SORAC 8 DAY 300.00 2,400.00

Total USD 88,047.95


HALLIBURTON

Conditions

NOTE

The cost in this analysis is good for the materials and/or services outlined within and shall be valid for 30 days from the date of this proposal. In order to meet your needs under this proposal with a high quality of service and responsive timing, Halliburton will be allocating limited resources and committing valuable equipment and materials to your area of operations. Accordingly, the discounts reflected in this proposal are available only for materials and services awarded on a frrst-call basis. Alternate pricing may apply in the event that Halliburton is awarded work on any basis other than as a first-call provider.

The unit prices stated in the proposal are based on our current published prices. The projected equipment, personnel, and material needs are only estimates based on information about the work presently available to us. At the time the work is actually performed, conditions then existing may require an increase or decrease in the equipment, personnel, and/or material needs. Charges will be based upon unit prices in effect at the time the work is performed and the amount of equipment, personnel, and/or material actually utilized in the work. Taxes, if any, are not included. Applicable taxes, if any, will be added to the actual invoice.

It is understood and agreed between the parties that with the exception of the subject discounts, all services performed and equipment and materials sold are provided subject to Halliburton's General Terms and Conditions contained in our current price list, (which include LIMITATION OF LIABILITY and WARRANTY provisions), and pursuant to the applicable Halliburton Work Order Contract (whether or not executed by you), unless a Master Service and/or Sales Contract applicable to the services, equipment, or materials supplied exists between your company and Halliburton, in which case the negotiated Master Contract shall govern the relationship between the parties. A copy of the latest version of our General Terms and Conditions is available from your Halliburton representative or at: http://www.halliburton.com/terms for your convenient review, and we would appreciate receiving any questions you may have about them. Should your company be interested in negotiating a Master Contract with Halliburton, our Law Department would be pleased to work with you to finalize a mutually agreeable contract. In this connection, it is also understood and agreed that Customer will continue to execute Halliburton usual field work orders and/or tickets customarily required by Halliburton in connection with the furnishing of said services, equipment, and materials. Any terms and conditions contained in purchase orders or other documents issued by the customer shall be of no effect except to confirm the type and quantity of services, equipment, and materials to be supplied to the customer. If customer does not have an approved open account with Halliburton or a mutually executed written contract with Halliburton, which dictates payment terms different than those set forth in this clause, all sums due are payable in cash at the time of performance of services or delivery of equipment, products, or materials. If customer has an approved open account, invoices are payable on the twentieth day after date of invoice.

Customer agrees to pay interest on any unpaid balance from the date payable until paid at the highest lawful contract rate applicable, but never to exceed 18% per annum. In the event Halliburton employs an attorney for collection of any account, customer agrees to pay attorney fees of 20% of the unpaid account, plus all collection and court costs.


Documents

9 7/B'' X Production Casing Design · PDF file9 7/B'' X 7'' Production Casing Design Report For ... Centralizer Parameters ... Macoodo Prospect MC 252 #I -9.875 X 7 prod Casing BP